.... Martin (1959) was the first to describe the effect of low salinity water on oil recovery. Using sandstone core samples, he compared an injection of seawater to that of freshwater, finding that oil recovery rose more after the injection of freshwater. However, the potential of LSWF was not established...

... GLDA solutions have pH of 4, as shown in Figures 2 and 3 . Sequential concentrations of 3 to 10wt% were injected at the tertiary mode after conventional seawater flooding, till no more oil was recovered at each stage of the flooding. Seawater was injected at two stages; before chemical injection...

... sample set was sourced from the Middle East field and the other was an outcrop from Eagle Ford Shale that is considered to be analogous to the one from the Middle East field. Three fracturing fluids, namely 2% KCl, 0.5 gpt slickwater and synthetic seawater, were used to treat the thin-section...

... Abstract Seawater-based fracturing fluids are used to generate a stable crosslinked fracturing fluid for higher formation temperatures primarily using two types of guar derivatives—HPG and CMHPG. Results are compared to other seawater-based fracturing fluid data in the literature, as well...

... nanofiltered (NF) seawater with formation water containing high total dissolved solids (TDS) under HP/HT conditions is discussed. A series of dynamic experiments was performed using a DSR-6000 dynamic scale loop at 330°F and 3,000 psi. Additionally, static experiments were conducted at room temperature...

... Abstract A new class of surfactants for enhanced oil recovery (EOR) applications has been developed in the form of petroleum sulfonate salt nanoparticle dispersions in seawater. These NanoSuractants (NS) are 10- to 60-nm particles of the seawater-insoluble petroleum sulfonate salts, one...

... Abstract As part of the continuous efforts to save freshwater resources in the Middle East, seawater-based fracturing fluid offers a high-potential solution to help save millions of gallons of fresh water while developing fracturing fluids for hydraulic fracturing applications. Scale...

... Abstract Seawater injection has demonstrated a successful and a well-established procedure for reservoir pressure maintaining and sweeping oil out of the reservoir. However, in most cases seawater by itself showed low incremental oil recovery, many research studies have shown that further...

... Abstract When carbonate in sandstone rocks exposed to seawater based acids, calcium sulfate will precipitate. Recently, chelating agents/seawater solutions were introduced to prevent scaling problem in sandstone formations. The objective of this study is to introduce DTPA (diethylene tri-amine...

... of Bandera and Berea sandstone cores after stimulation. In this study, DTPA and EDTA (ethylene di-amine tetra-acetic acid) chelating agents at high pH diluted with seawater combined with potassium carbonate were used to acidize Bandera and Berea sandstone cores. Core flooding system was used to acidize...

... in both injection seawater and field produced brine. It also out-performed the others in temperature stability for all types of brines. The other two surfactants were an amine oxide and an alpha olefin sulfonate. For the field brine conditions, the amine oxide proved to be the poorer performer in terms...

... is forming in the tube and clinging to the walls. Fig. 1 shows the schematic of dynamic tube blocking equipment. Rheology Testing Rheology testing was conducted to determine the proppant carrying capacity of fracturing fluid prepared using NF seawater. The gelling agent HPG was first hydrated...

... nanoparticles are dispersed in seawater, however nanoparticles stability in saline water have been reported to be a challenge. Therefore and in order to investigate the performance of these natural Zeolite nanoparticles on oil recovery, we first stabilize them in seawater. Natural Zeolite nanoparticles...

... Table 2 Saudi Arabia seawater variation percentages throughout the year. Value Sodium Calcium Magnesium Chloride Sulfate TDS Maximum value 17317 679 1858 32322 4337 55635 Minimum value 11545 507 1211 21496 2872 45817 % Variance from max. values 17...

... viscosity thereby decreasing the viscous fingering and allowing control on the mobility ratio, so it enhances the macroscopic sweep efficiency. Abstract This paper presents a new approach for flooding carbonate reservoirs using chelating agent fluid system prepared using seawater without dilution...

.... This study identified an inherently high calcium sulfate scale risk associated with the planned seawater injection in the new reservoir development and within the surface production fluid process facilities. Appropriate scale mitigation options including the potential impact of an injection seawater sulfate...

...). waterflooding enhanced recovery precipitation Brine solubility anhydrite calcium sulfate mechanism Upstream Oil & Gas concentration seawater injection agent EDTA injection carbonate reservoir seawater reservoir Oil Recovery chemical EOR method sea water dissolution Introduction...

... compared to the short chain (heptanoic acid) as confirmed by the measured contact angles. Twice dilution of Arabian Gulf seawater has been found to be a less effecient EOR fluid for wettability alteration as compared to undiluted Arabian Gulf seawater. This was confirmed by the changes in the measured...

... Abstract A study was initiated to investigate impact of co-mingling produced water with seawater. The objective of the study was to assess injectivity decline in power water injectors caused by introducing produced water into the seawater injection system using core samples from Arab-D...